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United States Patent |
5,351,767
|
Stogner
,   et al.
|
October 4, 1994
|
Drill pipe handling
Abstract
Multi-joint stands 126, 127 of drill pipe are assembled and disassembled in
a drilling rig 15 by use of a powered mousehole 11 concurrently with well
drilling operations conducted by use of a drill string top drive system
23. The powered mousehole 11 has an upwardly open bowl 45 in a floor 17 of
the drilling rig which can be rotated about a vertical axis 55. A pipe
joint 110 held in the bowl, and depending from it, can be screwed, with
controlled levels of torque, into connection with a second pipe joint 113
suspended vertically above the first joint 110 by a hoist system 13 which
is separate from hoisting equipment 19 carrying the top drive system 23
over a well bore 21. The second pipe joint 113 is held from rotation by a
tong assembly 12, but can move axially against a yieldable support 40 into
threaded connection with the first joint 110.
Inventors:
|
Stogner; Huey (League City, TX);
Watson; Craig A. (Katy, TX)
|
Assignee:
|
Globral Marine Inc. (Houston, TX)
|
Appl. No.:
|
972469 |
Filed:
|
December 21, 1992 |
PCT Filed:
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October 29, 1991
|
PCT NO:
|
PCT/US92/09257
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371 Date:
|
December 21, 1992
|
102(e) Date:
|
December 21, 1992
|
Current U.S. Class: |
175/162; 175/85; 175/203 |
Intern'l Class: |
E21B 019/00 |
Field of Search: |
166/77,77.5
175/57,85,162,203
|
References Cited
U.S. Patent Documents
3719238 | Mar., 1973 | Campbell et al. | 175/203.
|
4610315 | Sep., 1986 | Koga et al. | 175/85.
|
4738321 | Apr., 1988 | Oliver | 175/82.
|
4843945 | Jul., 1989 | Dinsdale | 175/85.
|
4854400 | Aug., 1989 | Simpson | 175/85.
|
Primary Examiner: Bui; Thuy M.
Attorney, Agent or Firm: Christie, Parker & Hale
Claims
What is claimed:
1. A method for making up, in a well drilling rig having a platform beneath
a derrick in which a hoist is movable along a vertical path above a well
bore, a drill pipe stand comprised of plural individual lengths of drill
pipe having cooperating pin and box threaded coupling moieties at their
opposite ends, comprising the steps of:
a) engaging a first pipe length adjacent the box end thereof in a yieldably
supported drivable pipe rotating device in vertically supported
torque-transmitting relation to the device for rotation about a
substantially vertical axis passing through a hole in the platform
adjacent the well bore with the first pipe length below the device in
essential alignment with said axis,
b) lowering the pin end of a vertically disposed second pipe length along
the axis into essentially aligned engagement with the box end of the first
pipe length,
c) holding the second pipe length from rotation about the axis while
yieldably supporting the second length for limited movement along the
axis,
d) driving the device to rotate the first pipe length about the .axis in a
direction causing the pin and box ends of the first and second pipe
lengths to thread together to form a drill pipe stand, and
e) releasing the stand from movement constraints associated with tire
driving step,
wherein the yieldably supporting operations afford limited longitudinal,
lateral and angular play of the pin and box ends of the two pipe lengths
relative to each other before and during performance of the driving step.
2. The method according to claim 1 wherein the pipe rotating device is
located in the hole below the platform surface.
3. The method according to claim 2 including mounting the device for
pivoting movement between positions in which the axis is disposed
vertically and in which the axis substantially intersects the hoist path
of movement.
4. The method according to claim 3 wherein the step of engaging the first
pipe includes disposing the pipe length in a tubular scabbard connected to
the device.
5. The method according to claim 4 including applying a force to the
scabbard to move the axis of the scabbard and the device against the bias
of gravity between said positions of the axis.
6. The method according to claim 1 wherein the drilling rig includes a
drill string direct drive system carried by the hoist and wherein the
steps of the method can be performed during operation of the direct drive
system to drill the well bore.
7. The method according to claim I including limiting the torque applied to
the first pipe length in performance of step d).
8. A method for making up, in a well drilling rig having a platform beneath
a derrick in which a hoist is movable along a vertical path above a well
bore, a drill pipe stand comprised of plural individual lengths of drill
pipe having cooperating pin and box threaded coupling moieties at their
opposite ends, comprising the steps of:
a) supporting a drivable annular pipe rotating member for rotation about a
substantially vertical axis in a hole in the platform adjacent the well
bore,
b) engaging a first pipe length adjacent the box end thereof in the annular
member in vertically supported torque-transmitting relation to the member
with the first pipe length below the annular member in essential alignment
with said axis,
c) moving the pin end of a vertically disposed second pipe length along the
axis into essentially aligned engagement with the box end of the first
pipe length,
d) holding the second pipe length from rotation about the axis while
yieldably supporting the second pipe length for limited movement along the
axis, and
e) rotating the annular member about the axis in a direction causing the
pin and box ends of the first and second pipe lengths to thread together
to form a drill pipe stand.
9. The method according to claim 8 including attaching the stand to a drill
pipe string in the well bore, and tilting the axis so that it
substantially intersects the path above the well bore.
10. The method according to claim 8 including limiting the torque applied
to the annular member in performance of step e).
11. A method for making up a section of drill pipe, comprising the steps
of:
a) positioning a lower housing on spring-biased legs in alignment with a
hole in a drilling platform;
b) positioning an upper housing on spring-biased legs over said lower
housing;
c) releasably attaching a lower end of a cable to a box end of a first
drill pipe joint;
d) suspending said first drill pipe joint from said cable and inserting
said first drill pipe through said lower housing;
e) receiving said box end of said first drill pipe joint with jaws in said
lower housing;
f) releasing said lower end of said cable from said first drill pipe joint
and attaching a lower end of the same or a different cable to a box end of
a second drill pipe joint;
g) suspending said second drill pipe joint from said same or different
cable and inserting a pin end of said second drill pipe joint into said
upper housing in engagement with said box end of said first drill pipe
joint;
h) securing said pin end in jaws in said upper housing;
i) rotating said jaws in said upper and lower housings with respect to each
other to thread said pin end of said second drill pipe into said box end
of said first drill pipe joint, wherein longitudinal movement between said
jaws in said upper and lower housings is taken up by said springs between
said upper and lower housings to form a section of joined pipe; and
j) releasing said jaws in said upper and lower housings and removing the
joined pipe section therefrom.
12. The method of claim 11, wherein said jaws in said lower housing are
fixed and said jaws in said upper housing are rotated in step i).
13. The method of claim 11, wherein said steps c) through j) are repeated
with a third drill pipe joint as said first drill pipe and with a double
joined pipe section as the second drill pipe joint to make a thribble.
14. The method of claim 11, wherein said threading in step i) is to a
predetermined torque.
15. A make-up and breakout tool, comprising:
a lower housing and an upper housing disposed above said lower housing,
each housing having a set of jaws for gripping pipe;
a first set of spring-biased legs for supporting said lower housing on a
platform having a hole formed therein, wherein said hole is aligned with
said jaws in said lower housing to receive a first pipe depending from
said lower housing;
a second set of spring-biased legs supporting said upper housing on said
lower housing with each set of jaws in alignment, wherein said
spring-biasing of said leg sets allows longitudinal, lateral and angular
play of said jaw sets with respect to each other and said hole;
means for releasably positioning a lower end of a second pipe in said jaws
of said upper housing in engagement with an upper end of said first pipe
held in said jaws of lower housing; and
means for rotating one of said jaw sets with respect to the other set to
threadably connect said first and second pipes, wherein travel is taken up
by compression of said springs between said upper and lower housing.
16. The apparatus of claim 15, further comprising a torque gauge for
ascertaining an amount of torque supplied by said rotating jaw.
17. Apparatus useful for making-up and breaking down multi-joint stands of
drill pipe in a well drilling rig concurrently with the performance of
drilling operations in the rig which includes a well bore location
vertically below a travelling block moveable along a vertical path in a
derrick disposed over the working surface of a drilling platform supported
on a foundation, the apparatus comprising:
an annular sleeve disposed in the platform working surface adjacent the
well bore and mounted for rotation about a substantially vertical axis
while carrying a load acting downwardly along the axis, the sleeve being
adapted to receive therein substantially along the axis a first joint of
drill pipe having a box end thereof disposed above the sleeve and
extending substantially along the axis to a lower pin end of the joint,
a driver coupled to the sleeve operable for rotating the sleeve in a
selected direction about the axis,
a mount yieldably supporting the sleeve and the driver on the foundation
for limited movement in selected directions relative to the axis,
pipe engaging means disposed above the sleeve operable for releasably
engaging a second joint and for holding a second joint from rotation while
affording vertical movement of a second joint substantially along the
axis.
18. Apparatus according to claim 17 wherein the sleeve is disposed below
the platform working surface in a hole in the platform.
19. Apparatus according to claim 17 including a tube extending from the
mount along the axis in a direction away from the sleeve for receiving a
pipe joint engaged in the sleeve.
20. Apparatus according to claim 19 in which the tube has a substantially
closed end remote from the sleeve, and means in the tube at said end for
resiliently supporting a pipe joint received in the tube.
21. Apparatus according to claim 20 wherein a portion of the tube adjacent
its closed end is rotatable about the axis.
22. Apparatus according to claim 19 wherein the mount is defined to enable
the axis to be tilted in a selected direction relative to the foundation.
23. Apparatus according to claim 22 in which the selected direction is
defined to enable the axis to substantially intersect the path of movement
of the travelling block.
24. Apparatus according to claim 22 including a powered tilting mechanism
operable for tilting the axis.
25. Apparatus according to claim 24 wherein the tilting mechanism is
operatively coupled to the tube.
26. Apparatus according to claim 17 wherein the mount defines a second axis
about which the first axis is tiltable in a selected direction.
27. Apparatus according to claim 26 wherein the mount yieldably supports
the sleeve and the driver at a location in the mount below the second
axis.
28. Apparatus according to claim 17 including hoist means in the derrick
substantially above the sleeve operable for lowering, into substantially
aligned engagement with a first joint received in the sleeve, the pin end
of a second joint of drill pipe.
29. Apparatus according to claim 28 wherein the hoist means comprises a
cable and resiliently deflectable means interposed between the cable and a
pipe joint supported by the hoist means.
30. Apparatus according to claim 28 wherein the pipe engaging means is
disposed in the rig for movement into and out of position above the
sleeve.
31. Apparatus according to claim 28 wherein the pipe engaging means
comprises a jaw assembly operable for clamping engagement with a pipe
joint, the jaw assembly being mounted to be secure from rotation about the
axis and to be substantially free to move along the axis.
Description
FIELD OF THE INVENTION
The present invention pertains to oil field drill pipe handling procedures
and equipment. More particularly, it pertains to procedures for making up
multi-joint stands of drill pipe by use of a rotary mousehole during top
drive drilling operations.
BACKGROUND OF THE INVENTION
Oil well drilling procedures are now well developed and known. Typically, a
rotating string of drill pipe, composed of individual sections (also
called "joints") of drill pipe each typically 30 feet in length, carries
at its lower end a drill bit which bores into the earth. As the bit bores
deeper, additional joints of pipe are added to the string. Until
relatively recently, the drill string typically was rotated about its axis
by use of a rotary table located on a drilling platform in combination
with a special section of drill string called a kelly joint or, more
simply, a kelly. The rotary table typically is located in the platform
floor directly below the path of vertical movement of a traveling block
suspended in a derrick erected over the platform. The kelly is a
non-round, often hexagonal, section of heavy-wall drill pipe, typically 42
feet in length, which forms the uppermost section of the drill string
during drilling operations using a rotary table. The rotary table includes
a power driven annular collar configured to slidably mate with the
non-round configuration of the kelly, thereby to rotate the drill string
and to power the drill bit.
When drilling with a rotary table and a kelly, the pipe string is drilled
"kelly down", i.e., the length of the kelly joint, after which the kelly
is raised above the rotary table. The drill string then is secured from
downward movement in the rotary table, and the kelly is disconnected from
the drill string. An additional 30 foot joint of drill pipe is added to
the string and the kelly is then reconnected to the drill string. The
string then is lowered through the rotary table to enable the kelly to
engage, adjacent its lower end, in driving relation to the rotary table
collar. Drilling operations are then resumed and continued to extend the
well bore another 30 feet or so, at which time it is necessary to add
another joint to the drill string. A new joint of drill pipe is added to
the drill string each time the well bore is extended 30 feet or so, and
each such addition requires performance of the operations described above.
In connection with oil and gas well drilling by use of rotary table
equipment, additional features of the drilling equipment were developed,
notably a mousehole and a rathole. A mousehole is a substantially
vertically disposed tubular sleeve located in the drilling rig with its
upper end at the platform closely adjacent the rotary table center. The
mousehole is used to hold the next joint of drill pipe which is to be
added to the drill string. The rathole is a somewhat larger diameter and
often longer length tubular sleeve or the like also located in the
drilling rig floor; it serves as a receptacle for the kelly.
Recently, a form of mechanism different from a rotary table has gained
widespread acceptance in the oil and gas drilling industry for rotating a
drill pipe string. That new equipment is known as a top drive. A top drive
drilling mechanism and related equipment is supported by and below the
traveling block for movement vertically along the well bore axis and for
connection directly to the drill string. The top drive mechanism includes
a motor, such as a DC electric motor, which operates to turn a coupling to
which the upper end of the pipe string can be connected. Use of top drive
drilling procedures eliminates the need for the long kelly joint and the
need for disconnecting the kelly joint from the drill string each time it
becomes necessary to increase the length of the drill string. Also, drill
pipe can be added to the drill string in units of two or three joint
"stands", i.e., multi-joint increments of drill string 60 or 90 feet in
length, with a corresponding reduction in man hours expended in drilling a
well of specified depth.
To take advantage of the drilling efficiencies obtainable with top drive
systems, it is now appropriate to make-up double or triple (thribble)
joint stands of drill pipe while drilling operations are in progress.
However, commercial drilling rigs are not normally equipped to do this
effectively, and so the pipe joints are made up into stands manually using
hoists, chains and tongs developed for use in rotary table drilling
procedures. Frequently the task of making up double or thribble stands of
drill string cannot be completed fast enough to keep up with drilling, and
so the efficiencies possible from use of top drive drill procedures are
not being fully realized.
A problem commonly encountered when making up doubles and thribbles for top
drive drilling is to ensure proper alignment of the tool joint ends. Each
joint has an externally threaded coupling moiety at one end, called a
"pin", and a cooperating internally threaded coupling moiety called a
"box", at its other end. Drill strings typically are assembled with each
joint in the string joint disposed pin end down. Because the travelling
block in a drill rig derrick generally cannot be moved laterally in the
derrick, a reserve pipe held in a mousehole must be angled for positioning
to a joint suspended by the travelling block or by other hoists located
other than directly vertically above the mousehole. Thus, stand make-up
procedures cannot take advantage of gravity to obtain proper alignment
between individual pipe joints being assembled to define a stand. Oil and
gas well drill pipe is heavy and thus is difficult to handle manually.
Misalignment of the pin and box ends of adjacent joints can slow the task
of making up a stand and can lead to galling or other thread mutilation
conditions. Additional problems encountered include applying the proper
amount of torque to one or the other of the joints being connected by use
of chain tongs. Usually, overall torque is measured only when the double
or thribble is attached to the top drive unit, and there is no measurement
or control of torque at each connection between joints in the stand.
U.S. Pat. No. 3,293,959 to Kennard discloses a pipe support well tool. The
device is mounted over the rathole on a drilling platform. A housing
includes a means for supporting a length of pipe to be added to the drill
string and clamping means for securing the pipe from rotation during
make-up with the kelly joint. The housing is mounted on spring legs such
that the pipe to be made up will be resiliently supported and upwardly
biased to the kelly joint. A winch having a cable and stabbing hook swings
the kelly joint into position over the housing and vertically aligns it
with the pipe joint supported by the housing.
Other U.S. patents of interest include U.S. Pat. Nos. 3,144,085, 3,212,578;
4,290,495 to Elliston; 3,662,842 to Bromell; 1,417,490 to Brandon;
1,908,818 to Brown; 2,142,022 to Volpin; 2,245,960 to Claire; 2,321,245 to
Reed; 4,403,666 to Willis; and 4,591,007 to Shaginian et at.
In view of the foregoing, it is apparent that a need exists for
improvements in the procedures and equipment available in top drive drill
rigs to enable more efficient and effective assembly of multi-joint stands
of drill pipe while top drive drilling procedures are occurring. Such
improvements desirably should include procedures and devices which take
maximum advantage of gravity to significantly reduce, if not eliminate,
the need for manual handling of single and plural pipe joints. Also, the
improvements desirably should include techniques and equipment for
accurately and efficiently aligning the pin and box ends of two joints to
be connected and for threading those joints together with known levels of
torque. Further, the equipment should be maximally workable and useful
with existing drill rig arrangements and procedures to avoid clutter on
the drilling platform and to reduce the need for retraining of rig
personnel. Further, the equipment providing the desired improvements
should be compatible with, and able to co-exist with, rotary table
drilling arrangements and procedures which have advantage under certain
drilling conditions.
SUMMARY OF THE INVENTION
This invention addresses the need identified above. It does so by providing
improved procedures and equipment for effectively and efficiently enabling
multi-joint stands of drill pipe to be assembled in a drilling rig during
the performance of top drive drilling operations without interfering with
such operations. Use of the improved procedures and equipment provided by
this invention permits better realization of the advantages and
efficiencies attainable with top drive drilling procedures.
Generally speaking, in terms of procedural aspects, this invention provides
a method for making up, in a well drilling rig having a platform beneath a
derrick in which a hoist is moveable along a vertical path above a well
bore, a drill pipe stand. The drill pipe stand is comprised of plural
individual lengths of drill pipe having cooperating pin and box threaded
coupling moieties at their opposite ends. The method includes supporting a
drivable annular pipe rotating member for rotation about a substantially
vertical axis in a hole in the platform adjacent the well bore. The method
also includes engaging a first pipe length adjacent the box end thereof in
the annular member in vertically supported, torque transmitting relation
to the member, with the first pipe length below the annular member in
essential alignment with that axis. Further, the method includes moving
the pin end of a vertically disposed second pipe length along the axis
into essentially aligned engagement with the box end of the first pipe
length. Another step in the method is that of holding the second pipe
length from rotation about the axis while yieldably supporting the second
pipe length for limited movement along the axis. Still another step in the
method is that of rotating the annular member about the axis in a
direction causing the pin and box ends of the first and second pipe
lengths to thread together to form a drill pipe stand.
DESCRIPTION OF THE DRAWINGS
The above-mentioned and other features and advantages of this invention are
more fully set forth in the following description of presently preferred
and other embodiments of the procedural and structural aspects of the
invention, which description is presented with reference to the
accompanying drawings wherein:
FIG. 1 is a fragmentary elevation view, partially in section and partially
in phantom, of a well drilling rig equipped with presently preferred
equipment according to this invention;
FIG. 2 is a simplified, substantially schematic elevation view, taken in a
direction at right angles to that FIG. 1, of the drilling rig which
includes a top drive drilling system and the improvements provided by this
invention;
FIG. 3 is a fragmentary elevation view taken along line 3--3 of FIG. 1;
FIG. 4 is an enlarged fragmentary elevation view, partially in section, of
a mousehole pivot drive mechanism which is a component of the equipment
shown in FIGS. 1 and 3;
FIGS. 5, 6 and 7, respectively, are fragmentary plan views of the relief
and reinforcement of certain of the structural beams depicted in FIG. 3
useful to accommodate the rotary mousehole mechanism shown in FIG. 3 and
to enable pivoting of it;
FIG. 8 is a partial elevation view, partially in section, of the rotary
mousehole drive and support arrangements according to a presently
preferred embodiment of the invention;
FIG. 9 is an elevation view taken along line 9--9 of FIG. 8;
FIG. 10 is a fragmentary elevation view illustrating additional aspects of
a portion of the structure shown in FIGS. 8 and 9;
FIG. 11 is a fragmentary elevation view of the lower portion of the
mousehole scabbard shown in FIGS. 8, 9 and 10;
FIGS. 12, 13 and 14 are views similar to that of FIG. 2 which, in
combination with FIG. 2, illustrate various steps in the procedure for
making up a multi-joint stand of drill pipe during top drive drilling
operations;
FIG. 15 is an elevation view, with certain portions broken away, of another
pipe stand make-up and breakdown rotary mousehole mechanism according to
this invention;
FIG. 16 is a view, partially in section, taken along line 16--16 in FIG.
15;
FIG. 17 is a bottom view of the mechanism shown in FIG. 15; and
FIG. 18 is a top view of that same mechanism.
DESCRIPTION OF THE ILLUSTRATED EMBODIMENT
A presently preferred drill pipe stand make-up and breakdown apparatus 10
according to this invention is shown in FIGS. 1 through 14. The principal
components of apparatus 10 are a powered rotary mousehole 11, a pipe
handling tong assembly 12, and a related hoist system 13. Apparatus 10 is
a component of a drilling rig 15 having a rig foundation 16 composed of
suitable structural beams suitably interconnected, on top of which a
platform working floor 17 is defined as shown in FIGS. 1 and 3. Rig 15
also includes a derrick 18 supported on foundation 16 above floor 17. As
shown in FIG. 2, the derrick includes a travelling block 19 which is
suspended on suitable cables below a crown block 20 at the top of the
derrick for movement along a vertical path which is aligned with the
centerline 21 of a well bore which passes through the center of a rotary
table assembly 22 disposed in concentric alignment with well bore
centerline 21.
The presently preferred usage of apparatus 10 is in an offshore drilling
rig, such as a jack-up drilling rig or a floating drilling rig, such as a
drill ship or semi-submersible drilling platform. It will be appreciated,
however, that the procedures and equipment provided by this invention can
also be used to advantage in land-based drilling rigs. For purposes of
example and illustration, apparatus 10 is described in the context of its
preferred usage in an offshore drilling rig.
As noted above, a benefit provided by this invention is better realization
of the advantages which can be obtained by use of drilling procedures
which apply rotary power to the upper end of a drill pipe string 24 at a
location in the drilling rig above its floor 17 by use of procedures and
equipment which do not rely upon the presence of a kelly at the upper end
of the drill string. Several kinds of such procedures and equipment are
known. Those several kinds of arrangements are collectively referred to
herein as drill string direct drive systems to distinguish them from
rotary table drive arrangements which apply rotary power to a drill string
indirectly via a kelly from a rotary table at the rig floor. The kind of
drill string direct drive which has proved most accepted in the industry
is that kind known as a top drive drilling system.
Accordingly, a top drive drilling system 23 is carried by and suspended
from travelling block 19, either directly from the travelling block as
shown in FIG. 2 or, if desired, from a lifting hook (not shown) carried by
the travelling block. The top drive drilling system can be a VARCO BJ
system manufactured by Varco International, Inc. As is now well known in
the drilling industry, top drive drilling systems include a motor and
dolly assembly for driving a power swivel to which the upper end of a
drill pipe string 24, aligned with well bore centerline 21, can be
connected. The drill pipe string extends through rotary table 22, which
normally is idle and is not used to turn the drill string during drilling
operations conducted by use of the top drive drilling system, and
downwardly into the desired well bore. Operation of the top drive drilling
system rotates drill string 24 to power a drill bit (not shown) connected
to the lower end of the drill string in a known manner. Travelling block
19 normally is guided in and constrained to only vertical motion along a
path which is collinear with well bore centerline 21.
Powered mousehole 11 is located in the drilling rig closely adjacent to,
and to the side of, rotary table 22. Where the powered mousehole is a
component of an offshore drilling rig, the preferred location for the
mousehole is forward of the rotary table between the rotary table and a
horizontal pipe racking and storage area outside derrick 18. The powered
mousehole preferably is disposed in a hole 26 in the rig platform so that
the top of the mousehole is located below the platform surface (see FIG.
10) so the hole can be closed by a hatch 27 when the mousehole is not in
use.
Tong assembly 12 preferably is located on the platform to the side, port or
starboard, of mousehole 11 and includes a base 28 which includes a
rotatable mounting for a preferably hollow non-round vertical post 29 to
which a carriage 30 is mounted for movement along post 29 but not for
rotation about the post. The mass of the carriage and of the equipment
carried by it preferably is counterbalanced by counterweights inside the
post, which counterweights are connected to the carriage via a cable (not
shown) passed over a pulley 31 at the top of the post. A horizontal
telescoping arm assembly 32 is mounted to the carriage and, at its end
remote from the carriage, mounts a tong jaw assembly 33.
Hoist system 13 is separate from and supplemental to the principal hoist
system in derrick 18 which includes travelling block 19. Hoist system 13
preferably includes a winch 36, such as an air driven winch commonly
called an air tugger, for reeling in and paying out a cable 37. Cable 37
passes over a sheave or pulley 38 which is suitably suspended in the
derrick at a desired, preferably high, location in the derrick. Cable 37
passes from the sheave to its free end to which is connected a pipe
elevator 39. The connection of elevator 39 to cable 37 preferably is via a
coupling 40 which preferably includes a vertically disposed compression
spring (not shown) so arranged in the coupling that the elevator is
resiliently connected to cable 37. The installation of hoist system 13 in
rig 15 is so arranged that the elevator normally hangs in the rig directly
above mousehole 1 I.
The principal component of apparatus 10 is powered mousehole 11. As shown
best in FIGS. 8, 9 and 10, the mousehole includes an annular elongate bowl
45 which can be cylindrical at its lower end 46 and which flares upwardly
and outwardly toward its upper end 47 which is located below the top
surface of platform floor 17 in platform hole 26. An outwardly extending
circumferential flange 48 is secured, preferably integrally, to the lower
end of the bowl. An annular externally toothed gear ring 49 is secured to
the underside of bowl flange 48, as by bolts 44, and serves as the outer
race of thrust and journal bearing, such as a deep groove ball bearing,
having an inner race ring 50. The inner race ring is secured, as by bolts
51, to a bottom plate 52 of a housing 54 in which the bowl is mounted for
rotation about a substantially vertical axis 55. Axis 55 is the active
axis of the powered rotary mousehole.
A motor 57 is mounted to an upper top portion of housing 54 and has a
driven shaft 58 which is coupled within the housing to a gear train 59,
the output gear of which meshes with the teeth of ring gear 49. Thus,
operation of motor 57, in one direction or the other, causes bowl 45 to be
driven, in one direction or the other, about axis 55 within housing 54.
The mount of torque transmitted to bowl 45 during operation of motor 57 is
controlled by a torque controller 60 which is associated with motor 57.
As shown best in FIGS. 8 and 10, the bottom plate 52 of housing 54 has
formed therein a hanger hole 62 concentric to axis 55. The upper end 63 of
an elongate mousehole scabbard tube 64 is supported by housing bottom
plate 52 in hanger hole 62. The scabbard tube preferably is hung, much
like a pendulum, from the housing and normally is urged by gravity into a
coaxial relation to axis 55. The scabbard tube is provided for receiving
and housing the major portion of the length of a drill pipe joint, such as
joint 110, received in the mousehole in the manner described below.
Mousehole housing 54 also includes a foundation plate 67 which is below and
preferably parallel to bottom plate 52. A hole 68, having a diameter
slightly larger than the outer diameter of scabbard tube 64, is formed in
the foundation plate concentric to axis 55 to enable the scabbard tube to
pass through the foundation plate. Also, a plurality of vertically
elongate spacer members 69 are secured to the foundation plate about hole
68 and depend from that plate. The spacer members support a scabbard guide
plate 70 below the foundation plate. A hole 71, similar to hole 68, is
formed in the guide plate to cooperate closely with the exterior of the
scabbard tube which passes through the guide plate. Plates 52, 67 and 70
cooperate with the scabbard tube to define an angularly stiff yet
releasable connection of the scabbard tube to the mousehole housing. The
scabbard tube can be pulled vertically out of the housing through the bowl
45.
Mousehole housing 54 is mounted, preferably to rig foundation 16, so that
the mousehole axis 55 can be tilted out of plumb relation into substantial
intersection with the path of vertical movement of travelling block 19 in
derrick 18. Tilting of the mousehole occurs about a horizontal tilt axis
72 which preferably is located below mousehole housing 54. Axis 72 is
defined by a pair of pivot axles 77 which are located on opposite sides of
the scabbard tube below housing foundation plate 67. Each axle is carried
in a respective pivot axle mount assembly 75.
As shown best in FIGS. 8 and 9, each pivot axle mount 75 is composed of
upper and lower bodies which, by virtue of the cooperation between them,
are vertically movable relative to each other. Each upper body (see FIG.
8) is comprised of a pair of axle support lugs 76 which are disposed
parallel to each other and which depend from the underside of housing
foundation plate 67. Adjacent their lower ends, they carry between them a
mousehole pivot axle 77 which defines mousehole pivot axis 72. Between the
lugs 76, the axle is circumferentially engaged by a journal bearing 78
which is supporting on a bearing carrier 79. The bearing carrier is
slidably received in a central aperture 82 of a vertically disposed,
substantially rectangular structural frame 83 disposed, in part, between
the opposing inner faces of lugs 76. A yieldable support member 84,
preferably provided in the form of a block-like rubber shock mount, is
engaged between the underside of the bearing carrier and the bottom of the
aperture within frame 83. Accordingly, the bearing carrier is yieldably
and resiliently supported in frame 83 by yieldable member 84 which is
defined to be sufficiently strong to carry the weight of the rotary
mousehole and any joints of drill pipe which may be disposed within the
mousehole at any time, as well as such additional vertical loads as may be
applied to the mousehole in its use.
The upper portion of frame 83 cooperates closely between the inner faces of
lugs 76, as shown in FIG. 8. Each frame 83 is supported on a structural
support bracket 86 defined within the rig foundation as a part of that
foundation. As shown in FIG. 3, existing offshore drilling rigs which
include rotary tables, usually include a pair of parallel, deep web
structural rotary table support beams 87, between which are disposed a
pair of smaller parallel rotary table skid beams 88, one of which is shown
in FIG. 3.
As shown in FIG. 3, a rotary mousehole according to this invention can be
installed in an existing offshore drilling rig in association with an
appropriate one of the rotary table support beams 87 by affixing, adjacent
a lower portion of that beam on the inner face of the web thereof, a pair
of mousehole support brackets 86 to respective ones of which mousehole
support frames 83 can be connected. To accommodate the mousehole,
particularly when it has the structure described above and shown in the
drawings, it may be appropriate to provide suitable clearance for the
mousehole by relieving portions of the upper and lower flanges of the
rotary table support beam to which the mousehole is connected and an upper
adjacent flange of the proximate rotary skid beam 88. If that is
necessary, those beam flanges are locally recessed and reinforced as shown
in FIGS. 5, 6 and 7. In FIG. 5, it is shown that the upper flange 89 of
the rotary table support beam 87 is recessed preferably by a relatively
smooth curve, as at 90, and a suitable doubler plate 91 is welded to the
unrelieved portions of the flange adjacent recess 90 to compensate for the
reduction in strength of the beam which would otherwise be experienced by
the presence of recess 90 in the beam flange. Similarly, FIG. 6 shows that
a lower flange 93 of the rotary table support beam 87 can be relieved,
preferably by a smoothly curved notch or recess 94, with compensation for
the presence of the recess in flange 93 being obtained by welding a
doubler plate 95 to the flange adjacent the recess. Similarly, FIG. 7
shows that an adjacent flange of the rotary table support beam 88 can be
relieved preferably by a smoothly curved recess 97, in the flange edge,
with compensation for that relief being provided by a suitable doubler 98.
Drive means are coupled between the rig foundation 16 and powered mousehole
11 for tilting the mousehole about its tilt axis 72 at times when
inclination of the mousehole axis 55 from plumb may be desirable in the
course of operations in the drilling rig. The mechanism for producing
tilting of the mousehole relative to the rig foundation is shown generally
in FIG. 3 and in more detail in FIG. 4. A mousehole tilt mechanism 100
includes a collar 101 which is clamped about the exterior of the mousehole
scabbard tube 64 a desired distance below the mousehole tilt axis 77.
Preferably the location of the collar is closely adjacent the lower
surface of the bottom flange 93 of the rotary table support beam to which
the mousehole is mounted in the manner described above. One end of a cable
102 is connected to collar 101 and is passed over a pulley 103 to a
vertically acting drive mechanism 104, which preferably is a piston and
cylinder assembly, suitably carried on the outside of beam 88 above pulley
103. The pulley can be carried on the bottom outer portion of beam 88 as
shown in FIG. 4. In the normal position of mechanism 100, gravity acting
upon the pendulum-like mousehole scabbard 64 causes the mousehole axis 55
to be vertical. If tilt of the mousehole is desired, actuator mechanism
104 is operated to pull on cable 102 to draw collar 101 toward pulley 103
and thereby impart the desired angle of tilt of the mousehole within the
range of tilt afforded to it. The tilted condition of the mousehole is
shown in FIG. 3.
FIG. 11 is a fragmentary elevation view of a lower portion of mousehole
scabbard 64. The scabbard tube, which has its upper end 63 hung in
mousehole housing 54, has connected to its lower end a tubular housing 106
via a coupling 107 which maintains the housing in alignment with the
portion of the mousehole scabbard above it, but permits the housing 106 to
rotate about the mousehole axis relative to the upper portion of the
mousehole. A plunger disc 108 is slidably disposed within the inside of
housing 106. The disc preferably is carried at the upper end of a
compression spring 109 which has its lower end supported by the
substantially closed lower end of housing 106. Spring 109 is a heavy duty
compression spring which is rated for loads in the range of from 600 to
about 6000 lbs. Spring 109 is a component of a resiliently yieldable
support for one or more drill pipe joints which may be received in the
mousehole scabbard at different times during use of mousehole 11.
Alternatively, if desired, the lower end of the scabbard tube can be
effectively continuous with, and not rotatable relative to, the upper
portions of that tube, and disc 108 can be rotatably carried by the upper
end of spring 109. In either event, rotation of a pipe joint in the
scabbard tube is accommodated at the lower end of the scabbard in a way
which protects the joint pin, and also the scabbard itself, from undesired
wear.
FIGS. 2, 12, 13 and 14 illustrate conditions at different stages in the
course of makingup a thribble (three-joint) stand 126 of drill pipe in
derrick 18 during the performance of drilling operations through rotary
table 22 by use of top drive drilling system 23. A first joint 110 of
drill pipe to be assembled into a multi-joint stand is engaged at its box
end by elevator 39 of hoist system 13. Hoist system 13 is operated to
lower joint 110 into mousehole 11 until its box end is at a desired
position closely above the top of mousehole bowl 45. Joint 110 is secured
in the mousehole by engaging suitable slips 111 (see FIG. 10) in a known
manner between the mousehole bowl and the joint below its box to hold
joint 110 from further downward movement in the mousehole. The slips
cooperate between the bowl and the exterior of the joint to transfer to
the joint torque applied to the bowl by operation of motor 57. The joint
is resiliently and yieldably supported on the spring mechanism provided at
the lower end of the mousehole scabbard (see FIG. 11) before slips 111 are
engaged with the joint and the mousehole bowl.
A second joint 113 of drill pipe is then engaged adjacent its box end by
elevators 39 and is lowered toward joint 110 in the mousehole. As the
lower pin end of joint 113 approaches the upper end of joint 110, the
lower portion of joint 113 above its pin is engaged in the jaws 33 of tong
assembly 12 to cause the pin end of joint 113 to properly align with and
engage with the box end of joint 110 during the last increments of
downward motion of joint 113 which then is co-axially aligned with
mousehole axis 55. The cooperation of the tong jaw assembly with the lower
end of joint 113 holds that joint from rotation about mousehole axis 55.
However, in view of the above described nature of the tong assembly, the
tong assembly yieldably holds the lower end of joint 113 so that it can
move further downwardly without significant resistance along post 29 as
mousehole 11 is operated to rotate joint 110 about axis 55 thereby to
cause the threads between the cooperating pin and box ends of joints 113
and 110 to thread together with the desired amount of torque. It will be
recalled that it is preferred that the connection of elevators 39 to cable
37 is a resilient connection and so joint 113 can be drawn down into fully
threaded engagement with joint 110 against the spring biased support for
joint 113. When joints 113 and 110 have been threaded together, the two
joint double stand 127 is withdrawn from the mousehole and set aside
temporarily in a doubles racking board 114 provided at a suitable
elevation in derrick 18.
A third joint 115 of drill pipe is then acquired by elevators 39 of hoist
system 13 and is lowered into the mousehole which is now empty. Joint 115
is secured by slips 111 into the mousehole in the manner described above.
The doubles stand 127 (composed of assembled joints 113 and 110) is then
recovered by elevators 39 from the doubles racking area within derrick 18
and is lowered into engagement with the box end of joint 115 in the
mousehole. This is accomplished by use of tong assembly 12 in the manner
described above. (see FIG. 13). The double stand 127 is assembled to the
third joint of the desired thribble stand with the desired amount of
torque by operation of the mousehole in the manner described above. The
completed thribble stand 126 of drill pipe (composed of joints 113, 110
and 115) can then be racked vertically in the derrick by use of a
thribbles racking board 116 as shown in FIG. 14. The operations described
above and illustrated in FIGS. 2, 12, 13 and 14 can be performed during
drilling operations performed by use of a drill string 24 disposed in the
well bore and operated by top drive drilling system 23.
During the performance of drilling operations by use of rotary table 22,
rather than top drive drilling system 23, mousehole 11 can be tilted, in
the manner described above, toward the rotary table to serve as an active
or passive mousehole in support of rotary table drilling operations.
FIG. 10 shows slips 111 interposed directly between the interior of bowl 45
and the exterior of drill pipe joint 110 below the box end of that joint.
The situation as shown in FIG. 10 is that which can occur where the drill
pipe joint is of relatively large diameter. If a drill pipe joint is of
smaller diameter, a suitable mousehole bowl insert 120 (see FIGS. 8 and 9)
can be used with the bowl to, in effect, reduce the inner diameter of the
bowl to a diameter with enables slips 111 to be used with a smaller
diameter pipe joint. The bowl insert 120 preferably is a sleeve which
flares outwardly and upwardly along at least the major portion of its
length with the same degree of flare as the inner walls of bowl 45. The
difference between the inner and outer diameters of the sleeve is defined
to adapt the bowl for use with a pipe joint having an outer diameter
within a specified range of diameters. As shown in FIGS. 8 and 9, when the
insert sleeve is inserted into bowl 45, the outer surfaces of the sleeve
register with the inner surfaces of the bowl so that the upper ends of the
insert and the bowl are substantially coplanar. To assure that the insert
will rotate with the bowl and not slip relative to the bowl as the bowl is
rotated about axis 55, the insert sleeve can carry, preferably adjacent
its lower end, one or more outwardly extending projections 121 which
cooperate in corresponding grooves 122 defined in the inner wall of the
bowl. The projections and grooves cooperate as keys and keyways to secure
the insert from turning about axis 55 relative to the bowl. If desired, a
plurality of downwardly open, semi-circular recesses 123 can be provided
in the bottom end of the insert to cooperate with a suitable tool useful
for extracting an insert sleeve from the mousehole bowl.
Referring to FIGS. 15 through 18, a drill pipe make-up and break-out tool
130, according to another embodiment of this invention, comprises an upper
housing 131 which is supported on a lower housing 132 by a plurality of
spring biased legs 133. The lower housing has a plurality of spring biased
legs 134.
The upper housing preferably comprises a reversible rotatable jaw 135 in an
enclosure 137 suitable for rotating a pipe 138 having a coupling end 139
with threads 140 known in the art as "pin". A motor 141, such as a
hydraulic motor, provides motive force to the jaw 135.
The lower housing 132 preferably comprises a fixed (non-rotatable)jaw 142
in an enclosure 143 suitable for holding immobile a pipe 144 under a
radial force; the jaw 142 releasably grips the pipe. In an alternative
arrangement, the jaw 142 can be rotatable. The lower housing 132 includes
a releasable back-up plate 145 having an aperture suitable for retaining
the pipe 144 suspended therefrom at a neck 146 formed in the pipe 144 in
an absence of gripping force from the jaw 142. The neck 146 is formed by
increasing a diameter of the coupling end 147 of the pipe 144, known in
the art as a tool joint "box". Design and operation of such pipe gripping
jaws 135, 142, as well as back-up plate 145, are well known in the art.
Further details regarding the jaws 135, 142 and the back-up plate 145 may
be found in Kennard which is hereby incorporated herein by reference.
The tubular upper housing legs 133 comprise an upper leg section 136 having
a distal enclosure portion 149 for a spring 150. The upper leg distal
portion 149 is in telescoping engagement with a lower leg section 151.
Compression of the spring 150 preferably allows the upper leg section 136
to travel a suitable distance in the lower leg section 151. The upper leg
section 136 is preferably secured to upper housing by support plates 153.
The lower leg section 151 is preferably secured to the lower housing 132
by either support plates 154 or 155 depending upon a spatial arrangement
of legs 133 on the upper housing 131.
The tubular lower housing legs 134 comprise an upper leg section 156 having
a distal enclosure portion 157 for a spring 152. The lower housing upper
leg distal portion 157 is in telescoping engagement with a lower leg
section 158. Compression of the spring 152 preferably allows the upper leg
section 157 to travel a suitable distance in the lower leg section 158.
The upper leg section 157 is secured to the lower housing 132. The lower
leg section 158 is preferably secured to the upper leg section 156 by
means of a support plate 159.
In a preferred device of the kind shown in FIGS. 15 through 18, the lower
housing 132 has a torque gauge 160 for ascertaining the torque applied by
the rotatable jaw 135 on the pipe 138. A commercially available torque
gauge for this purpose is disclosed in the aforementioned U.S. Pat. No.
3,293,959 to Kennard. The tool 130 threadably joins one section of drill
pipe to another. In operation, lower housing 132 of the tool 130 is
positioned on the spring bias legs 134 over a mousehole 162 or other
aperture of suitable depth in a platform 163. As shown in FIGS. 15 and 16,
the lower housing 132 can be connected to the upper end of a mousehole via
support plate 159. The bottom drill pipe 144 is lowered box side up
through the upper and lower jaws 135, 142 by a hoist (not shown) to
position the neck 144 of the box 147 adjacent the back-up plate 145. The
length of the pipe is received by the mousehole 162. The back-up plate 145
is then closed under the neck 146, thereby retaining the pipe 144. The
lower jaw 142 is clamped on the box 147 of pipe 144 to inhibit rotation
thereof. The top pipe 138 is similarly hoisted and lowered into the upper
jaw 135 of the upper housing 131, wherein the pin 139 is clamped by the
jaw 135. To facilitate proper alignment of the complementary threads 140
of the pin 139 with the threads of the box 147, spring biased legs 132,
134 allow for lateral, longitudinal and angular play in the upper and
lower housings 131, 132. Activation of the jaw rotating motor 141 in a
proper direction of rotation (generally clockwise) joins the pipes 138,
144 by threading the pin 139 into the box 147.
To release the joined pipe, the upper and lower jaws 135, 142 are unclamped
and the back-up plate 145 is opened. The double, for example, may be
hoisted for use in the drill string. An additional joint may be added to
make a thribble. A double can be lowered further into a mousehole having
sufficient depth so that the box end of the top joint is held at the
backup plate 145 in the lower housing and another single can be joined to
the double as previously mentioned above. Alternatively, especially where
the mousehole is not deep enough to receive the double, the double can be
hoisted and set aside while a single is lowered into the tool 130 so that
the box end is held at the back-up plate 145. The double is then joined to
the single as described above. The tribble, once made, is stored in the
derrick for immediate use or back in the finger board until needed. The
upper end of the thribble is typically attached to the top drive assembly
sufficiently high in the derrick, e.g., at least 90 feet, so that the
lower end of the thribble can be attached to the drill string which
typically is held in slips in the floor of the drilling platform, such as
in the collar of a rotary table which may be is present but is not used
during top drive drilling operations.
In tool 130, the pipe 144 as mentioned previously, is held immobile by the
lower jaw 142. Consequently, the top pipe 138 is drawn toward the bottom
pipe 144 as the pin 139 is threaded into the box 147. Longitudinal travel
between the upper housing 131 with respect to the lower housing 132,
typically about 5 inches, is taken up by compression of the springs 150 in
the legs 133 of the upper housing 132.
The breakout procedure for double or tribble lengths of pipe reverses the
make-up procedure described above. The thribble, for example, is lowered
into the jaws 135, 142 of tool 130 which is positioned over the mousehole
162 until the box portion neck 146 of the bottom or middle joint
(depending on the mousehole depth) is adjacent the back-up plate 145 which
is closed. The jaws are clamped to the pipe and the top joint is broken
out by operating the rotating jaw 135 in a direction (usually
counter-clockwise) suitable for unthreading the top joint. The upper jaw
135 is unclamped and the released joint is hoisted away. The remaining
double length is then positioned so that the bottom joint box is held by
the back-up plate 145 and the top joint is unthreaded.
The foregoing descriptions of the presently preferred procedures and
structures according to this invention has been presented by way of
example, rather than as an exhaustive catalog of all procedural and
structural forms which this invention may take. Workers skilled in the art
to which this invention pertains will appreciate that variations in the
procedures described above, and modifications of the structures described
above, can be used to implement the advances provided by this invention
without departing from the scope of the invention. For that reason, the
following claims are to be interpreted and applied liberally in the fair
context of the preceding descriptions and of the relevant state of the
art.
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